U.S. patent application number 10/600037 was filed with the patent office on 2004-01-15 for method and apparatus for locking out a subsurface safety valve.
This patent application is currently assigned to Weatherford/Lamb, Inc.. Invention is credited to Deaton, Thomas Michael, Hill, Thomas G. JR., Hodge, Rory L., Simpson, Neil A.A..
Application Number | 20040007365 10/600037 |
Document ID | / |
Family ID | 30118518 |
Filed Date | 2004-01-15 |
United States Patent
Application |
20040007365 |
Kind Code |
A1 |
Hill, Thomas G. JR. ; et
al. |
January 15, 2004 |
Method and apparatus for locking out a subsurface safety valve
Abstract
The present invention is directed to a method and apparatus of
locking out a subsurface safety valve (SSV) in a hydrocarbon
wellbore. A lockout tool is provided that is dimensioned to be
received within the housing of the safety valve. The lockout tool
generally comprises an elongated housing, and an expander mandrel
slidably received within the housing. Together, the housing and
expander mandrel are run into the wellbore and landed into the
housing of the SSV such that the end of the expander mandrel opens
the flapper valve. A portion of the lockout tool housing shoulders
against the flow tube in the SSV to drive the flow tube downward,
thereby maintaining the flapper of the SSV in its open position. As
the expander mandrel moves downward through the hard seat of the
SSV, the mandrel engages the flow tube and expands it against the
hard seat. In this manner, the flow tube is expanded into
permanent, frictional engagement with the hard seat. This, in turn,
locks the flapper member of the SSV in its open position.
Inventors: |
Hill, Thomas G. JR.;
(Kingwood, TX) ; Deaton, Thomas Michael; (Houston,
TX) ; Simpson, Neil A.A.; (Aberdeen, GB) ;
Hodge, Rory L.; (Spring, TX) |
Correspondence
Address: |
MOSER, PATTERSON & SHERIDAN, L.L.P.
3040 POST OAK BOULEVARD, SUITE 1500
HOUSTON
TX
77056-6582
US
|
Assignee: |
Weatherford/Lamb, Inc.
|
Family ID: |
30118518 |
Appl. No.: |
10/600037 |
Filed: |
June 20, 2003 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
60395521 |
Jul 12, 2002 |
|
|
|
Current U.S.
Class: |
166/386 ;
166/323 |
Current CPC
Class: |
E21B 43/103 20130101;
E21B 34/14 20130101; E21B 2200/05 20200501; E21B 34/102
20130101 |
Class at
Publication: |
166/386 ;
166/323 |
International
Class: |
E21B 034/14 |
Claims
We claim:
1. A lockout tool for locking a subsurface safety valve in the open
position, wherein the safety valve comprises a pressure containing
body having a bore therethrough, a valve closure member disposed in
the bore moving between an open and a closed position, a flow tube
axially moveable in the body, a non-moveable seat adjacent the
valve closure member, and an actuating means for translating the
flow tube longitudinally in the bore, said lockout tool comprising:
an elongated housing adapted to fit inside the subsurface safety
valve; a mandrel moveable in the housing; at least one dog, which,
upon controlled movement of the mandrel, engages and moves the flow
tube in a direction to place the valve closure member in its open
position; and a plurality of expander points in substantially
circumferential arrangement inside the housing, and adapted to move
into radial engagement with an inside diameter of the flow tube
after the at least one dog has moved the flow tube to open the
valve closure member in its open position, said expander points
being urged to move radially outward with sufficient force to yield
and expand a diametrical portion of the flow tube into engagement
with the non-moveable seat in the safety valve, thereby permanently
locking the valve closure member in the open position.
2. The lockout tool of claim 1, wherein the housing comprises a
ball housing portion that houses the plurality of expander
points.
3. The lockout tool of claim 2, wherein the expander points define
balls.
4. The lockout tool of claim 2, wherein the expander points define
dogs.
5. The lockout tool of claim 1, wherein the housing defines a
plurality of sub-housings.
6. The lockout tool of claim 5 wherein the plurality of
sub-housings comprises: a no-go housing, the no-go housing having
an outer beveled surface for landing onto a beveled profile along
the inner surface of the safety valve; an upper housing, with at
least one dog residing within the upper housing; and a ball
housing, the expander points residing along the ball housing
7. The lockout tool of claim 6, further comprising a stem at least
partially slidably received within the housing.
8. The lockout tool of claim 7, wherein the stem comprises an upper
portion configured to be coupled to a run-in tool, and a lower
extension portion coupled to the expander mandrel.
9. The lockout tool of claim 8, wherein the upper portion of the
stem is a part of a wire line stem used in connection with oil
field jars,
10. The lockout tool of claim 8, wherein the upper portion of the
stem is connected to a string of coiled tubing for run-in.
11. The lockout tool of claim 7, wherein: the lockout tool further
comprises a carrier sleeve axially movable within the housing; and
the at least one dog comprises at least one flow tube dog carried
by the carrier sleeve within the housing.
12. The lockout tool of claim 11, wherein the lockout tool further
comprises at least one locking dog for maintaining the position of
the lockout tool within the safety valve during the lockout
process.
13. The lockout tool of claim 12, wherein the locking dog is also
carried by the carrier sleeve.
14. The lockout tool of claim 13, wherein the lockout tool further
comprises at least one carrier sleeve no-go dog carried by a
carrier sleeve within the housing, the at least one carrier sleeve
no-go dog shifting the carrier sleeve downward in response to
downward movement of the stem.
15. The lockout tool of claim 14, wherein the stem further
comprises a shoulder for contacting the carrier sleeve no-go dog
when the stem is urged downward, thereby contacting the at least
one carrier sleeve no-go dog and urging the carrier sleeve
downward.
16. The lockout tool of claim 15, wherein the lockout tool further
comprises at least one carrier sleeve locking dog for preventing
the carrier sleeve from moving before the shoulder of the stem
contacts the at least one carrier sleeve no-go dog.
17. The lockout tool of claim 1, wherein the expander mandrel is
moveable in the housing in response to mechanical force.
18. The lockout tool of claim 1, wherein the expander mandrel is
moveable in the housing in response to hydraulic force.
19. A lockout tool for locking a subsurface safety valve in the
open position, the safety valve comprising a housing having a bore
therethrough, a flapper member disposed in the bore, the flapper
being movable between an open position and a closed position by a
flow tube, a non-moveable seat adjacent the flapper member, and an
actuating means for translating the flow tube longitudinally in the
bore in order to maintain the flapper in the open position, the
lockout tool comprising: an elongated housing dimensioned to be
received within the subsurface safety valve, the housing having a
bore therethrough, and having a recess; a mandrel received within
the bore of the housing, and being moveable along a longitudinal
axis of the housing, the mandrel including an enlarged diameter
portion; and a plurality of expander points radially disposed
within the recess of the housing, the expander points being
arranged to ride along the mandrel as the mandrel is received
within the lockout tool housing, and to be urged outwardly as the
enlarged diameter portion of the mandrel passes through the
plurality of expander points, thereby causing the expander points
to engage an inside diameter of the flow tube such that the
expander points expand a diametrical portion of the flow tube into
engagement with the non-moveable seat so as to lock the flapper in
the open position.
20. The lockout tool of claim 17, further comprising: at least one
dog which, upon controlled movement of the mandrel, engages and
moves the flow tube in a direction to maintain the flapper in the
open position.
21. The lockout tool of claim 18, wherein the expander points
define balls.
22. The lockout tool of claim 18, wherein the expander points
define dogs.
23. A method for locking a subsurface safety valve in the open
position, the safety valve comprising a housing having a bore
therethrough, a flapper member disposed in the bore, the flapper
member being movable between an open position and a closed position
by a flow tube, a non-moveable seat substantially surrounding the
flow tube, and an actuating means for translating the flow tube
longitudinally in the bore in order to maintain the flapper member
in the open position, the method comprising the steps of: running a
lockout tool into a wellbore, the lockout tool comprising: an
elongated housing dimensioned to be received within the subsurface
safety valve, the housing having a bore therethrough, and having a
recess; a mandrel received within the bore of the housing, and
being moveable along a longitudinal axis of the housing, the
mandrel including an enlarged diameter portion; and a plurality of
expander points radially disposed within the recess of the housing,
the expander points being arranged to ride along an outer diameter
of the mandrel as the mandrel is received within the lockout tool
housing, and to be urged outwardly as the enlarged diameter portion
of the mandrel passes through the plurality of expander points;
locating the lockout tool into the subsurface safety valve; moving
the flow tube downward, thereby opening the flapper member; urging
the expander mandrel downward relative to the lockout tool housing,
causing the enlarged diameter portion to pass through the plurality
of expander points, and thereby causing the expander points to
engage an inside diameter of the flow tube such that the expander
points expand a diametrical portion of the flow tube into
engagement with the non-moveable seat in the safety valve so as to
lock the flapper member in the open position.
24. The method of claim 23, wherein the non-moveable seat in the
safety valve defines the hard seat for receiving the flapper member
when the flapper member is in the closed position.
25. The method of claim 24, wherein the lockout tool is run into
the wellbore on a slickline.
26. The method of claim 25, wherein the expander mandrel is urged
downwardly by using a set of jars.
27. The method of claim 25, wherein the lockout tool is run into
the wellbore using coiled tubing.
28. The method of claim 27, wherein the expander mandrel is urged
downwardly by applying hydraulic pressure through the coiled
tubing.
29. The method of claim 23, wherein the expander points define
balls.
30. The method of claim 23, wherein the expander points define
dogs.
31. The method of claim 23, wherein the step of urging the expander
mandrel downward is accomplished mechanically.
32. The method of claim 23, wherein the steo of urging the expander
mandrel downward is accomplished hydraulically.
33. A method for expanding a first tubular body into a surrounding
second tubular body, comprising the steps of: attaching the first
tubular to a lockout tool, the lockout tool comprising: an
elongated housing dimensioned to be received within the first
tubular, the housing having a bore therethrough, and having a
recess; a mandrel received within the bore of the housing, and
being moveable along a longitudinal axis of the housing, the
mandrel including an enlarged diameter portion; and a plurality of
expander points radially disposed within the recess of the housing,
the expander points being arranged to ride along an outer diameter
of the mandrel as the mandrel is received within the lockout tool
housing, and to be urged outwardly as the enlarged diameter portion
of the mandrel passes through the plurality of expander points;
running the first tubular and the attached lockout tool into a
wellbore; urging the expander mandrel downward relative to the
lockout tool housing, causing the enlarged diameter portion to pass
through the plurality of expander points, and thereby causing the
plurality of expander points to engage an inside diameter of the
first tubular such that the expander points expand a diametrical
portion of the first tubular into engagement with the second
tubular so as to lock the first tubular into frictional engagement
with the second tubular at a selected depth.
34. The method of claim 34, further comprising the steps of:
pulling the lockout tool out of the wellbore; running into the
wellbore with an expander tool; locating the expander tool at a
depth in the wellbore adjacent the first tubular; actuating the
expander tool; translating the expander tool along a desired length
within the first tubular, thereby further expanding the first
tubular into further frictional engagement with the second
tubular.
35. The method of claim 34: wherein the expander tool is a
hydraulically actuated, rotary expander tool; and wherein the
method further comprises the step of rotating the rotary expander
tool while translating the expander tool along a desired length
within the first tubular.
36. The method of claim 34, wherein the expander points define
balls.
37. The method of claim 34, wherein the expander points define
dogs.
Description
RELATED APPLICATIONS
[0001] This new application for letters patent claims priority from
an earlier-filed provisional patent application entitled "Method
and Apparatus for Locking Out a Subsurface Safety Valve." That
application was filed on Jul. 12, 2002 and was assigned Application
No. 60/395,521.
BACKGROUND OF THE INVENTION
[0002] 1. Field of the Invention
[0003] This invention is related generally to safety valves. More
particularly, this invention pertains to subsurface safety valves
deployed in a wellbore for controlling fluid flow through a
production tubing string. More particularly still, the present
invention relates to a lockout tool for locking out a safety valve
into its open position.
[0004] 2. Description of the Related Art
[0005] Subsurface Safety Valves (SSVs) are often deployed in
hydrocarbon producing wells to shut off production of well fluids
in emergency situations. Such SSVs are typically fitted into
production tubing in the wellbore, and operate to block the flow of
formation fluids upwardly through the production tubing should a
failure or hazardous condition occur at the well surface.
[0006] SSVs are designed either to be slickline retrievable, or
tubing retrievable. If a safety valve is configured to be
slickline/wireline retrievable (WRSSV), it can be easily removed
and repaired. If the SSV forms a portion of the well tubing, it is
commonly known as "tubing retrievable" (TRSSV). In this instance,
the production tubing string must be removed from the well to
perform any safety valve repairs.
[0007] The subsurface safety valve has a flapper member or "plate,"
that is moveable between an open position and a closed position. In
this respect, the flapper member is typically pivotally mounted to
mate with a hard seat. When the flapper is in its open position, it
is held in a position where it pivots away from the hard seat,
thereby opening the bore of the production tubing. However, the
flapper is biased to its closed position against the seat.
[0008] The flapper of the safety valve is held open during normal
production operations. This is done by the application of hydraulic
fluid pressure transmitted to an actuating mechanism. A common
actuating mechanism is a cylindrical flow tube, which is maintained
in a position adjacent the flapper by hydraulic pressure supplied
through a control line. The control line resides within the annulus
between the production tubing and the well casing. Pressurized
hydraulic fluid is delivered from the surface through the control
line, and bears against a piston. The piston, in turn, acts against
the cylindrical flow tube, which in turn moves across the flapper
valve to hold the valve open. When a catastrophic event occurs at
the surface, hydraulic pressure is interrupted, causing the
cylindrical flow tube to retract, and allowing the safety valve to
quickly close. When the safety valve closes, it blocks the flow of
production fluids up the tubing. Thus, the SSV provides automatic
shutoff of production flow in response to well safety, conditions
that can be sensed and/or indicated at the surface. Examples of
such conditions include a fire on an offshore platform, sabotage to
the well at the earth surface, a high/low flow line pressure
condition, a high/low flow line temperature condition, and operator
override.
[0009] Removal and repair of the tubing retrievable safety valve is
costly and time consuming. It is usually advantageous to delay the
repair of the TRSSV yet still provide the essential task of
providing well safety for operations personnel while producing from
the well. To accomplish these objectives; the safety valve is
disabled in the open position, or "locked out". This means that the
flapper member is pivoted and permanently held in the fully opened
position. In normal circumstances, if the well is to be left in
production, a WRSSV may be inserted in the well, often in lockable
engagement inside a bore within the locked out tubing retrievable
safety valve. Because of the insertion relationship, the WRSSV
necessarily has a smaller inside diameter than the TRSSV, thereby
reducing the potential hydrocarbon production rate from the well.
Locking out the safety valve will not eliminate a need for
remediation later, but the lockout and use of the WRSSV will allow
the well to stay on production (most often, with a reduced
production rate) or perform other work functions in the tubing
until the TRSSV can be repaired or replaced.
[0010] Various types of mechanical lockouts have been proposed.
Examples are found in U.S. Pat. Nos. 3,696,868; 3,786,865; and
3,786,866. In these applications, various additional parts are
necessary to enable the valve to be locked out. Such parts are
integral to each and every valve. It is interesting to note that
modern SSVs are extraordinarily reliable, and such lockout
mechanisms are not used except in a small fraction of the total
valve population; yet, integral lockout mechanisms are present in,
and add unnecessary cost to, most prior art SSV assemblies.
Further, integral lockout mechanisms are not normally operated for
extended periods of time, often for years, and are not normally or
even periodically actuated. For these reasons, the integral lockout
mechanisms may themselves fail to work for various reasons such as
sand, corrosion, scale and asphaltine buildup.
[0011] Other inventors have realized the disadvantages of integral
lockout mechanisms, and inventions have been disclosed in U.S. Pat.
No. 4,574,889 (Pringle '889), U.S. Pat. No. 4, 577,694 (Brakage,
Jr. '694) and U.S. Pat. No. 6,059,041 (Scott '041). These
inventions recognize a need to remove integral lockout mechanisms
and requisite structure from the SSV.
[0012] Pringle '889 teaches a method and apparatus of locking out a
subsurface safety valve. The apparatus provides a housing having a
bore and one downwardly directed shoulder adjacent the bore. The
shoulder makes an outward indentation in the flow tube at a
predetermined location whereby the indentation will engage a
downwardly directed shoulder in the housing, preventing the flow
tube from moving to the closed position. The mechanism has the
limitation of making only a single indentation during any stroke of
the lockout tool. This results in very high localized stresses at
the point of impact, causing embrittlement of the material, and
possibly undesirably punching through the flow tube. Further, there
is no mechanism disclosed to index the punching mechanism to
another radial position. Because the SSV assembly is often placed
thousands of feet below the earth's surface, using the device
taught by Pringle '889 to make second or subsequent indentations in
the flow tube in any other radial position is unreliable.
Therefore, the operator can only be assured of making a single
indentation or, worse, a single penetration of the flow tube. When
penetration occurs a metal flap is formed, usually connected by a
very small area of metal resembling the infamous "hanging chad" of
Florida election lore. A SSV that is locked out in such a manner
may not stay locked out when slickline, coiled tubing or other
remediation procedures are performed on the well below the SSV. In
this respect, when such service tools are pulled up through the
locked out SSV, shearing the indentation or flap can occur,
resulting in an undesirable unlocking of the valve. Such unlocking
can lead to the well again being prematurely shut in, and a
resultant loss of production.
[0013] Brakage, Jr. '694 teaches a method and apparatus for
permanently locking a shiftable valve member in a well conduit in
an open position. The invention provides a spring metal band that
is adapted to expand from a contracted, run-in position to a
radially enlarged locking position. The band thereby holds the
valve member in an open position. The band is deposited in the SSV
by a specially adapted slickline tool. While this invention
satisfies the need to remove the integral lockout from the safety
valve, an additional part, (the spring metal band) is introduced
into the SSV assembly downhole. Further, after deposition, the
metal band is not positively attached to anything inside the SSV,
but is held in place only by the frictional force exerted by the
spring metal band. Certain flow regimes in the wellbore can
collapse the spring metal band and allow it to flow out of the SSV,
thereby causing the well to inadvertently shut in. This phenomenon
has been observed.
[0014] Scott' 041 is similar to Brakage Jr. '694 wherein deposition
of a radially deflectable blocking member relative to the SSV is
provided to enable lockout. In a described embodiment of the
apparatus, a lockout tool has mechanisms which effect latching of
the tool to an internal profile of a safety valve, displacement of
a flow tube of the safety valve to open the safety valve, and
deposition of an expandable ring to prevent closure of the safety
valve. This invention only partially satisfies the need to remove
the integral lockout from the safety valve, because it requires
expensive special profiles and again introduces an additional part
to enable the lockout. While this is an arguable design improvement
over Brakage Jr. '694, certain flow regimes still may flow the
radially deflectable blocking member out of the SSV, thereby
causing the well to inadvertently shut in.
[0015] There is a need, therefore, for a lockout tool that requires
no additional integral SSV parts or expensive special profiles to
enable lockout of an SSV. Further, there is a need for a lockout
tool that can be deployed by slickline or coiled tubing, and does
not attempt to permanently deposit any parts in the safety valve to
enable lockout. Still further, there is a need for a lockout tool
that does not require special profiles or shoulders in the valve,
and can be used to lock out virtually any type of safety valve made
by any manufacturer.
SUMMARY
[0016] The present invention is directed to a method and apparatus
of locking out a subsurface well safety valve (SSV) in the open
position. The SSV itself includes a housing having a bore, a valve
closure member in the bore that is movable between an open position
and a closed position, a flow tube axially movable in the housing
for selectively moving the valve closure member from its closed
position to its open position, and an actuator for translating the
flow tube longitudinally, e.g., a spring-biased piston.
[0017] The present invention first provides an apparatus that
enables a well operator to lock the downhole safety valve into its
open position. A lockout tool is provided that is dimensioned to be
received within the housing of the safety valve. The lockout tool
first comprises a stem. The stem connects the lockout tool to a
run-in tool, such as a slickline. The lockout tool also comprises
an elongated housing. The housing includes a ball housing portion
that houses a plurality of radially disposed balls. Next, the
lockout tool comprises an expander mandrel. The expander mandrel is
connected to the lower end of the stem by means of a stem extension
member. The expander mandrel is received within the housing of the
lockout tool.
[0018] A method for "locking out" the safety valve is also
provided. In operation, the lockout tool is landed into the housing
of an SSV such that the balls are adjacent a non-movable member in
the SSV, e.g., the hard seat. The lockout apparatus includes, in
one aspect, a set of flow tube dogs and a set of locking dogs.
These dogs are disposed intermediate the stem and the housing of
the lockout tool. When the stem (and attached expander mandrel) are
run into the SSV, the flow tube dogs are landed on top of the flow
tube, while the locking dogs are positioned adjacent an internal
recess in the SSV housing. As the expander mandrel is urged
downward, the locking dogs move radially outward, fixing the
lockout tool in the SSV housing. Further movement still of the
mandrel extends the flow tube dogs into contact with the flow tube.
Still further movement of the mandrel moves the flow tube downward,
thereby opening the flapper member.
[0019] The balls in the ball housing are at a depth adjacent the
safety valve's hard seat. The expander mandrel is urged further
downwardly relative to both the lockout tool housing and the safety
valve housing. The expander mandrel includes an enlarged diameter
portion. As the expander mandrel is moved downward within the SSV,
the enlarged outer diameter portion of the mandrel system engages
the balls, forcing them radially outward. The balls, in turn,
contact the flow tube and expand the flow tube into permanent,
radial and frictional engagement with the hard seat. The flapper
member of the SSV is thereby locked in its open position,
preventing the flow tube from returning to the closed position.
[0020] In summary, the method of the present invention in one
aspect includes the steps of lowering the lockout tool in a well,
locating in the SSV to be locked out, locking the tool in position,
moving the flow tube downward thereby opening the flapper member,
and from the inside of the bore, outwardly expanding a portion of
the flow tube's circumference at a predetermined location whereby
the expanded portion firmly engages a non-moveable portion in the
housing of the SSV, thereby preventing the flow tube from returning
to the closed position. After locking out the safety valve, the
lockout tool of the present invention is removed from the well. A
result of the expansion operation is engagement between the
expanded portion of the flow tube and the non-moveable parts in the
safety valve, thereby causing a very high friction force
therebetween. The expansion force may also slightly expand the
non-moveable metallic parts behind the flow tube, thereby forming
an in-situ locking profile. This locking profile engages the
expanded portion of the flow tube, further inhibiting the flow tube
and the valve from moving to the closed position.
BRIEF DESCRIPTION OF THE DRAWINGS
[0021] So that the manner in which the above-recited features of
the present invention are attained and can be understood in detail,
a more particular description of the invention, briefly summarized
above, may be had by reference to the appended drawings. In some
instances, moving parts are shown in solid black for ease of
reference. It is to be noted that the appended drawings illustrate
only typical embodiments of this invention and are therefore not to
be considered limiting of its scope, for the invention may admit to
other equally effective embodiments.
[0022] FIG. 1 presents a side elevational view of a permanent
lockout tool of the present invention, in one embodiment. The
lockout tool is shown in its run-in position.
[0023] FIG. 2 is a side view of the lockout tool of FIG. 1, in
cross-section. More visible in this view are two expander balls at
the lower end of the tool. The lockout tool is designed to be
mechanically activated.
[0024] FIG. 3A presents a cross-sectional view of the permanent
lockout tool of FIG. 2. In this view, the lockout tool has been
landed within a subsurface safety valve. It can be seen that a
lower end prong of the tool has contacted the flapper within the
valve assembly, forcing the flapper to open.
[0025] FIG. 3B is a cross-sectional view of the lockout tool of
FIG. 3A, taken across line B-B of FIG. 3A. More visible in this
view are three carrier sleeve locking dogs pushing outward against
an upper housing of the lockout tool. The three carrier sleeve
locking dogs are supported by slots machined into the stem
extension member.
[0026] FIG. 3C is a cross-sectional view of the lock out tool of
FIG. 3A. Here, the view is taken across line C-C of FIG. 3A. Seen
more readily in this view are flow tube dogs and locking dogs
radially disbursed around the stem extension, and carried by a
carrier sleeve.
[0027] FIG. 3D provides a cross-sectional view of the lockout tool
of FIG. 3A, taken across line D-D of FIG. 3A. Visible in this view
are carrier sleeve no-go dogs disposed within the housing, and
around an expander mandrel. The carrier sleeve no-go dogs are
carried by a carrier sleeve.
[0028] Next, FIG. 3E provides a cross-sectional view through line
E-E of FIG. 3A. Visible in this view are a plurality of radially
disposed expander balls within a ball housing. The balls are
arranged around the expander mandrel. A surrounding string of
production tubing is seen.
[0029] FIG. 4A presents a side elevational view, in cross-section,
of the permanent lockout tool of the present invention. In this
view, the stem and stem extension members are beginning to be
pushed downward into the lockout tool. A shear pin supporting the
upper stem has been sheared.
[0030] FIG. 4B shows a cross-sectional view of the lockout tool of
FIG. 4A, taken across line B-B of FIG. 4A. Visible again in this
view are three carrier sleeve locking dogs pushing outward against
the upper housing. The three carrier sleeve locking dogs remain
supported by the slots machined into the stem extension member.
[0031] FIG. 4C provides a cross-sectional view of the lockout tool
of FIG. 4A. The cut is taken across line C-C. The flow tube dogs
and locking dogs are again shown disposed around the stem
extension. The locking dogs have not yet backed outwardly, but
remain adjacent the stem extension.
[0032] FIG. 4D shows a cross-sectional view of the lockout tool of
FIG. 4A, taken across line D-D. In the view, both the stem
extension member and the expander mandrel are seen within the
carrier sleeve no-go dogs.
[0033] FIG. 4E gives a cross-sectional view of the lockout tool of
FIG. 4A, cut through line E-E. There is no change in the relative
position of the expander balls as compared to FIG. 3E. In this
regard, the expander balls remain fully retracted.
[0034] FIG. 5A presents the lockout tool, again in cross-section.
In this view, the stem continues to be driven downward into the
lock out tool. The locking dogs have now popped outwardly from the
stem extension, and have engaged a profile in the safety valve
housing.
[0035] FIG. 5B provides a cross-sectional view of the tool of FIG.
5A, taken across line B-B. There is no relative change in position
of the carrier sleeve locking dogs from the view of FIG. 4B.
[0036] FIG. 5C shows the lockout tool of FIG. 5A, in cross-section.
The view is taken across line C-C. In this view, it can be seen
that the locking dogs have popped outwardly into the profile of the
valve housing.
[0037] FIG. 5D is a cross-sectional view of the lock out tool of
FIG. 5A. Here, the view is taken across line D-D of FIG. 5A. There
has been no relative movement of the carrier sleeve no-go dogs in
this view as compared to FIG. 4D. Both the stem extension and the
expander mandrel are seen within the carrier sleeve no-go dogs.
[0038] FIG. 5E creates a cross-sectional view of the tool of FIG.
5A, taken across line E-E, and showing again the plurality of
expander balls. There is again no change in the relative position
of the expander balls as compared to FIG. 3E.
[0039] FIG. 6A is a cross-sectional view of the lockout tool of
FIG. 5A, and shows the next step in the tool actuation process. The
stem continues to be driven downward into the lockout tool. In this
view, the flow tube dogs have also popped outwardly into the recess
in the valve housing. This enables the flow tube dogs to also clear
a shoulder in an upper housing.
[0040] FIG. 6B presents a cross-sectional view of the tool of FIG.
6A. The view is taken across line B-B of FIG. 6A. There is no
relative change in position of the carrier sleeve locking dogs from
FIG. 5B.
[0041] FIG. 6C demonstrates another cross-sectional view of the
tool of FIG. 6A, taken across line C-C. In this view, it can be
seen that both the flow tube dogs and the locking dogs have
expanded outwardly relative to the stem extension.
[0042] FIG. 6D shows a cross-sectional view of the lockout tool of
FIG. 6A. The cut is through line D-D of FIG. 6A. The carrier sleeve
no-go dogs are again seen disposed within the flapper valve
housing, and around the stem extension member. However, the
expander mandrel is no longer seen, as it has been urged below line
D-D.
[0043] FIG. 6E creates a cross-sectional view of the tool of FIG.
6A, taken across line E-E. There is still no change in the relative
position of the expander balls as compared to FIG. 3E, meaning that
the expander balls remain retracted.
[0044] FIG. 7A is a side elevational view, in cross-section, of the
permanent lockout tool of the present invention, presenting the
next step in the tool actuation process. In this view, the stem
continues to be driven still further into the lockout tool. This
has enabled the carrier sleeve locking dogs to clear an enlarged
outer diameter portion of the stem extension member. A lower
shoulder in the stem extension member has now engaged the no-go
dogs.
[0045] FIG. 7B provides a cross-sectional view of the tool of FIG.
7A, taken across line B-B of FIG. 7A. It can be seen that the
carrier sleeve locking dogs have been able to move inwardly due to
the reduced outer diameters of the slots in the stem extension.
[0046] FIG. 7C shows a cross-sectional view of the tool of FIG. 7A.
Here, the view is taken across line C-C. Visible again in this view
are flow tube dogs and locking dogs radially disposed around the
stem extension member. It can be seen that the outer diameter of
the stem extension is enlarged relative to the cross-sectional view
of FIG. 6C.
[0047] FIG. 7D creates a cross-sectional view of the lockout tool
of FIG. 7A, with the view cut across line D-D. A lower shoulder
below the enlarged outer diameter portion of the stem extension
member has engaged the carrier sleeve no-go dogs. This allows the
stem extension member to push downwardly on the carrier sleeve
no-go dogs and attached carrier sleeve.
[0048] Next, FIG. 7E provides a cross-sectional view through line
E-E. There is yet no change in the relative position of the
expander balls as compared to FIG. 3E.
[0049] FIG. 8A presents yet another cross-sectional view of the
tool of the present invention, in one embodiment. The next step in
the tool actuation step is presented. In this view, the stem
continues to be driven downward into the lockout tool. The flow
tube dogs have extended further outwardly in order to shoulder
against the top of the flow tube in the safety valve. As the stem
is driven downward, it will drive the flow tube downwardly.
[0050] FIG. 8B provides a cross-sectional view of the tool of FIG.
8A, with the view taken across line B-B. Three carrier sleeve
locking dogs are again visible adjacent the carrier sleeve. The
diameters of the slots in the stem extension is now reduced.
[0051] FIG. 8C shows a cross-sectional view of the lock out tool of
FIG. 8A, cut across line C-C. The flow tube dogs and locking dogs
are seen radially disbursed about the carrier sleeve. The flow tube
dogs are fully expanded outwardly against the inner diameter of the
safety valve housing, and are in position to exert downward force
against the flow tube.
[0052] FIG. 8D gives a cross-sectional view of the lock out tool of
FIG. 8A, shown through line D-D of FIG. 8A. The carrier sleeve
no-go dogs are seen riding with the carrier sleeve.
[0053] FIG. 8E shows a cross-sectional view of the tool of FIG. 8A,
taken across line E-E. There remains no visible change in the
relative position of the expander balls as compared to FIG. 3E.
[0054] FIG. 9A presents a cross-sectional view of the permanent
lockout tool of FIG. 8A. In this view, the stem continues to be
driven downward into the housing of the tool. The carrier sleeve
and connected flow tube dogs are seen driving the flow tube
downward. Also, the stem extension member is driving the carrier
sleeve no-go dogs and connected carrier sleeve downward.
[0055] FIG. 9B provides a cross-sectional view of the tool of FIG.
9A. The view is taken across line B-B of FIG. 9A. The locking dogs
are now seen adjacent the carrier sleeve locking dogs around the
carrier sleeve.
[0056] FIG. 9C is a cross-sectional view of the lock out tool of
FIG. 9A, taken across line C-C of FIG. 9A. The flow tube dogs are
fully expanded outwardly against the inner diameter of the safety
valve housing, and are in position to exert downward force against
the flow tube.
[0057] FIG. 9D is a cross-sectional view of the lock out tool of
FIG. 9A, taken across line D-D of FIG. 9A. Visible in this view are
carrier sleeve no-go dogs disposed within the flapper valve
housing, and around the expander mandrel. The carrier sleeve no-go
dogs continue to be driven downward by the stem extension
member.
[0058] FIG. 9E creates a cross-sectional view of the lockout tool
of FIG. 9A, taken across line E-E. There remains no change in the
relative position of the expander balls as compared to FIG. 3E such
that the expander balls remain retracted. However, the flow tube is
now visible adjacent the balls.
[0059] FIG. 10A presents the next step in the actuation process for
the lockout tool after the step of FIG. 9A. FIG. 10A is another
cross-sectional view of the lockout tool. In this view, the stem
and connected stem extension member have been driven further
downward into the housing for the safety valve. The flow tube dogs
have now moved the flow tube to the end of its downward stroke. The
flapper valve is fully opened by the flow tube.
[0060] FIG. 10B provides a cross-sectional view of the lockout tool
of FIG. 10A, taken across line B-B. The carrier sleeve locking dogs
continue to move downward through the safety valve housing with the
stem and the carrier sleeve.
[0061] FIG. 10C shows a cross-sectional view of the tool, with the
view being taken through line C-C. The flow tube dogs are again
visible, and remain fully expanded outwardly against the inner
diameter of the safety valve housing.
[0062] FIG. 10D demonstrates a cross-sectional view of the lockout
tool, cut through line D-D of FIG. 10A. The carrier sleeve no-go
dogs continue to be driven downward by the lower shoulder in the
stem extension member.
[0063] FIG. 10E shows the lockout tool of FIG. 10A, in
cross-section. The view is taken across line E-E. There is again no
change in the position of the expander balls relative to the flow
tube of the safety valve as compared to FIG. 3E. The flow tube
remains visible circumferentially around the ball housing keeping
the flapper in its fully open position.
[0064] FIG. 11A is a cross-sectional view of the lockout tool, in
its next step of tool actuation. In this view, the stem is moving
still further downward into the safety valve. The connected stem
extension member is now moving downwardly inside the flow tube. In
addition, the carrier sleeve no-go dogs have popped outwardly into
a recess in the upper housing, allowing the stem extension to also
move downwardly relative to the carrier sleeve and connected no-go
dogs. Most importantly, an enlarged diameter portion of the
expander mandrel is now contacting the expander balls.
[0065] FIG. 11B provides a cross-sectional view of the lockout tool
of FIG. 11A, taken across line B-B. The position of the carrier
sleeve locking dogs relative to the upper housing has not changed
from the view of FIG. 10B.
[0066] FIG. 11C shows the lockout tool of FIG. 11A, in
cross-section. The view is taken across line C-C. There is also no
change in the position of the flow tube dogs relative to the tool
housing.
[0067] FIG. 11D gives another cross-sectional view of the tool of
FIG. 11A. Here, the view is taken across line D-D. The carrier
sleeve no-go dogs, which have been urged outwardly into a recess in
the housing, are adjacent the enlarged diameter portion of the stem
extension member.
[0068] Next, FIG. 11E provides a cross-sectional view through line
E-E. The plurality of expander balls is again seen. It can be seen
that the diameter of the expander mandrel has been enlarged
relative to the diameter shown in previous "E-E" cross-section
views. This causes the expander balls to be urged outwardly against
the flow tube.
[0069] FIG. 12A presents a cross-sectional view of the lockout tool
of FIG. 11A. FIG. 12A provides the final step in the lockout
process. In this view, it can be seen that the expander mandrel has
been driven through the flapper of the safety valve. The expander
balls and flow tube dogs have retracted, allowing the tool to be
later removed from the wellbore with tension placed in the
slickline (or other working string).
[0070] FIG. 12B is a cross-sectional view of the tool of FIG. 12A,
taken across line B-B. The stem extension member has been moved
through the tool housing to the extent that the upper end of the
stem extension member is adjacent the locking dogs.
[0071] FIG. 12C provides a cross-sectional view taken across line
C-C of FIG. 12A. It can be seen that the flow tube dogs have
cleared the enlarged diameter portion of the stem extension. The
flow tube dogs are recessing inward to a reduced diameter cut in
the stem extension.
[0072] FIG. 12D shows the tool of FIG. 12A in cross-section, with
the view being taken across line D-D. The carrier sleeve no-go dogs
slideably receive the stem extension member.
[0073] FIG. 12E shows the lockout tool, in cross-section. The view
is taken across line E-E of FIG. 12A. The expander balls have
retracted and are no longer acting against the radial dimension of
the flow tube.
[0074] FIG. 13 presents a cross-sectional view of an alternate
embodiment of the lockout tool of the present invention. In this
arrangement, a grooved and spiraled spline is placed around the
expander mandrel at the level of the enlarged diameter portion.
[0075] FIG. 14 presents a perspective view of an expander point
that might be used in lieu of an expander ball. The expander point
of this figure is a dog. A plurality of radially disbursed dogs
would be deployed around the ball housing where the dogs are
used.
[0076] FIG. 15 shows an alternate embodiment for the lockout tool
100 of FIG. 1. In this embodiment, the lockout tool is
hydraulically activated. The lockout tool is seen in a side,
cross-sectional view.
DETAILED DESCRIPTION OF CERTAIN EMBODIMENTS
[0077] FIG. 1 presents a perspective view of a lockout tool 100 of
the present invention, in one embodiment. In this view, the lockout
tool 100 is shown in its run-in position. The lockout tool 100 is
designed to be landed within a tool 50 to be expanded within a
hydrocarbon wellbore (not shown in FIG. 1). An example of such a
tool is a subsurface safety valve 50 (also not shown in FIG.
1).
[0078] The present invention will be described in connection with a
tubing retrievable surface controlled subsurface flapper type
safety valve. It will be understood, however that the present
invention may be used with other types of subsurface safety valves,
including those having different type valve closure members such as
balls, and those having different type actuation methods, such as
subsurface controlled (i.e., velocity, dome charged, and injection)
safety valves. In addition, and as will be described in further
detail below, the lockout tool may be used to radially expand a
selected portion of any tubular into engagement with a surrounding
second tubular within a wellbore.
[0079] Regardless of the type, the subsurface safety valve 50
("SSV") will have certain standard features (seen in FIG. 3A).
First, the valve 50 will have a pressure containing body 52. This
body 52 typically defines an elongated tubular housing having a
bore 55 therethrough. The valve 50 will also have a moveable flow
tube 54 disposed within the housing 52. The flow tube 54 moves
along the longitudinal axis of the housing 52 in order to
selectively open and close a valve closure member 60. The valve
closure member 60 is commonly referred to as a "flapper plate," or
just "flapper."
[0080] The flapper 60 is pivotally mounted onto a non-moveable
element such as a hard seat 58. The hard seat 58 is mounted within
the housing 52, typically below the flow tube 54. The hard seat 58
defines a short tube or ring that is dimensioned to receive the
flow tube 54 when the flapper 60 moves to its closed position.
[0081] The flow tube 54 is biased in a position that is retracted
from the hard seat 58. Likewise, the flapper 60 is biased in its
closed position against the hard seat 58. The biasing force is
typically provided by a powerful spring (not shown). It is only
when the biasing force acting against the flow tube 54 is overcome,
that the flow tube 54 can move through the hard seat 58 and open
the flapper 60. However, where the SSV 50 malfunctions and the flow
tube 54 cannot move through the hard seat 58 in order to urge the
flapper 60 open, the lockout tool 100 is employed. Thus, the
present invention provides an apparatus for moving the flow tube 54
downward through the hard seat 58, and holding the flapper 60 in
its open position. The present invention also provides a method for
engaging and mechanically moving the flow tube 54 through the hard
seat 58, and then expanding the flow tube 54 into permanent
frictional engagement with the surrounding hard seat 58. In this
way, the flow tube 54 is locked into a position holding the flapper
member 60 permanently in the open position.
[0082] Referring again to FIG. 1, the lockout tool 100 generally
comprises first an elongated stem 110. In one arrangement, the stem
110 defines an upper stem portion 112, and an upper stem extension
portion 114, or "stem extension portion." The separate upper stem
112 and upper stem extension 114 portions are seen in FIG. 2. The
stem 110 has a top end 102 designed to be connected to a run-in
tool, such as a wire line apparatus (not shown). Alternatively, the
stem 110 may be deployed at the end of a string of coiled tubing
(also not shown).
[0083] The lockout tool 100 next comprises a housing 120. In one
arrangement, the housing 120 comprises several tubular portions,
including a no-go housing 130, an upper housing extension 152, an
upper housing 150 and a ball housing 160. These separate housing
portions are also shown in FIG. 2. The no go housing 130, upper
housing extension 152, upper housing 150, and ball housing 160
together form a single elongated housing 120 configured to receive
the stem 110 when the lockout tool 100 is actuated. The use of
separate housings 130, 150, 160 assist in assembly of the tool
100.
[0084] In the perspective view of FIG. 1, a slot 153 can be seen in
the upper housing 150. Preferably, three elongated slots are
radially disposed around the upper housing 150. As will be
described more fully below, each of the elongated slots 153
receives a flow tube dog 186. The flow tube dogs 186 engage the
flow tube 64 of the safety valve 50 in order to drive it downward,
thereby placing the flapper 60 in its open position.
[0085] Disposed within the housing 120 are a plurality of expander
points 105. The expander points 105 in one arrangement are radially
disposed within the ball housing 160 at a lower end of the lockout
tool 100. In the arrangement described below in connection with
FIGS. 4A through 12A, the expander points 105 define radially
disbursed balls. The balls 105 are preferably fabricated from a
hardened material, such as carbide. As will be shown, the expander
balls 105 are urged radially outward against the flow tube 54 (or
other tubular to be expanded) in order to "lock" the flapper 60 of
the safety valve 50 into its open position. However, it is
understood that the expander points 105 may define any outwardly
movable protrusion, such as a plurality of hammers, e.g., shaped
dogs, placed in an array. FIG. 14 presents a perspective view of an
individual hammer 105'.
[0086] The lockout tool 100 next comprises an expander mandrel 170.
The expander mandrel 170 is connected to a bottom end of the stem
extension member 114 within the housing 120. The expander mandrel
170 is urged downwardly relative to the lockout tool housing 120 as
the stem 110 is received within the safety valve housing 52. As
more fully shown in the cross-sectional view of FIG. 2, the
expander mandrel 170 is dimensioned to have a varying diameter,
including an enlarged diameter portion 176. As the expander mandrel
170 is urged downwardly within the housing 120, the expander balls
105 are forced to ride outwardly against the diameter 176 of the
expander mandrel 170. This causes the balls 105 to expand the flow
tube 54 in order to lock the flapper member 60 into its open
position. More specifically, the expander balls 105 expand the flow
tube 54 of the safety valve 50 into frictional engagement with a
surrounding non-movable member, such as the hard seat 58.
[0087] Finally, the lockout tool 100 comprises a lower end prong
104. The prong 104 extends through a lower opening in the housing
120, and extends below the housing 120. The lower end prong 104 is
used to contact the flapper member 60 in the safety valve 50 as the
lockout tool 100 is lowered within the wellbore. In one aspect, the
outer diameter of the prong 104 is greater than the inner diameter
of the lockout tool housing 120, thereby preventing the expander
mandrel 170 from retreating back within the housing 120 upon
pullout.
[0088] Referring again to FIG. 2, FIG. 2 presents a cross-sectional
view of the lockout tool 100 of FIG. 1. Additional details of the
lockout tool 100 are seen. First, the upper stem portion 112 is
seen. In one arrangement, the upper stem portion 112 defines an
elongated solid metal body. In one aspect, the upper stem 112 is a
part of a wire line stem used in connection with oil field jars,
such as spang jars. The jars are used to hammer downwardly upon a
tool within the wellbore by alternately raising the slickline and a
connected weighted wire line stem, and dropping the wire line and
connected weighted wire line stem upon a steel bar. Thus, the upper
stem 112 in the lockout tool 100 may be the steel bar within a set
of oilfield jars.
[0089] Connected at the lower end of the stem 110 is the stem
extension portion 114. In the arrangement of FIG. 2, the stem
extension portion 114 also defines an elongated metal shaft. The
stem extension 114 has a diameter dimensioned to be slideably
received within the housing 120 of the lockout tool 100. Downward
force against the stem 110 causes the stem extension member 114 to
move downward within (or relative to) the housing 120 of the
lockout tool 100.
[0090] As noted, the lockout tool 100 also comprises a housing 120.
As shown in FIG. 2, the housing 120 defines an elongated tubular
body. The housing 120 is divided, in one aspect, into several
separate portions. First, the housing comprises a no-go housing 130
at an upper end. The no-go housing 130 has an inner diameter
dimensioned to receive the upper stem 112 and the stem extension
114 portions of the stem 110. The no-go housing 130 is connected to
the stem 110 via a temporary mechanical connection 140. In the
arrangement of FIG. 2, the temporary mechanical connection 140
defines one or more shear pins. Sufficient downward force on the
upper stem 112 will cause the shear pin 140 to shear, thereby
releasing the upper stem 112 from the no-go housing 130.
[0091] A top cap 142 is optionally placed above the no-go housing
130 in order to provide further support for the temporary
mechanical connection 140. The top cap 142 has a stem channel 143
that assists in guiding the stem 110 as it slides within the no-go
housing 130. An optional lock ring 146 and lock ring spacer 147 are
also provided below the top cap 142. The lock ring 146 prevents the
upper stem 112 from backing out of the no-go housing 130 due to
compression of the power spring (not shown) in the SSV 50 during
the tool actuation process.
[0092] Optional vents 139 are provided within the no-go housing
130. The vents 139 provide fluid communication between the inner
and outer diameter surfaces of the no-go housing 130 during the
tool actuation process. This, in turn, further enables the upper
stem 112 to move downwardly relative to the housing 120, and to
displace any fluid found within the inner diameter of the no-go
housing 130, and other housing portions, e.g., upper housing
150.
[0093] The housing 120 next comprises an upper housing 150. The
upper housing 150 likewise defines an elongated tubular body. The
upper housing 150 is disposed below the no-go housing 130. The
upper housing 150 includes an inwardly facing shoulder 151 having
upper and lower shoulder surfaces. Optional vents 159 are provided
within the upper housing 150.
[0094] In the arrangement of FIG. 2, an upper housing extension 152
is disposed intermediate the no-go housing 130 and the upper
housing 150. An upper end of the upper housing extension 152 is
threadedly connected to the no-go housing 130. Similarly, a lower
end of the upper housing extension 152 is threadedly connected to
the upper housing 150. A separate set of vents 157 is optionally
placed within the upper housing extension 152.
[0095] Finally, the housing 120 comprises a ball-housing portion
160. The ball housing 160 also defines an elongated tubular member.
An upper end of the ball housing 160 is, in one aspect, threadedly
connected to a lower end of the upper housing 150. Vents 169 are
seen disposed in the ball housing 160. In its lower end, the ball
housing 160 includes a recess 166 for receiving a plurality of
expander balls 105. As noted, and as will be explained in greater
detail below, the expander balls 105 are urged radially outward
against the non-moveable element 58 of the safety valve 50 when the
lockout tool 100 is actuated.
[0096] As noted, the lockout tool 100 of FIG. 1 and FIG. 2 next
comprises an expander mandrel 170. The expander mandrel 170 has an
upper end 172 and a bottom end 174. The upper end 172 of the
expander mandrel 170 is connected to a lower end of the stem
extension member 114. The lower end 174 of the expander mandrel
170, in turn, extends proximate to the lower end of the ball
housing 160. The lower end 174 of the expander mandrel 170 includes
a lower end prong 104 that extends below the ball housing 160. In
one aspect, the lower end prong 104 is a separate piece threadedly
connected to the lower end 174 of the expander mandrel 170. In the
particular arrangement shown in FIG. 2, and as noted above, the
lower end prong 104 has an outer diameter that is greater than the
inner diameter of the ball housing 160. This further helps to keep
the stem 110 (including the stem extension 114) and inner mandrel
170 from retracting upward relative to the lockout tool housing
120, especially during pullout.
[0097] In order to enable and assist the movement of the stem 110
and the inner mandrel 170 within the housing 120, various dogs are
employed. These preferably include (1) at least one carrier sleeve
locking dog 182; (2) at least one locking dog 184; (3) at least one
flow tube dog 186; and (4) at least one carrier sleeve no-go dog
188. Those of ordinary skill in the general art of designing
wellbore tools will understand that dogs are utilized to provide
releasable connections between tubular members. Dogs may be biased
inward or outward in order to selectively achieve relative movement
between tubular members upon release. Alternatively, dogs may not
be biased, but are urged to move in response to forces from
adjacent tubular members.
[0098] The dogs 182, 184, 186, 188 of the present invention are
carried along by a sleeve 180. The carrier sleeve locking dog 182,
the flow tube dog 186 and the carrier sleeve no-go dog 188 are
connected via a carrier sleeve 180, while the locking dog 184
resides adjacent the carrier sleeve 180. The relative functions of
the carrier sleeve locking dogs 182, the locking dogs 184, the flow
tube dogs 186 and the carrier sleeve no-go dogs 188 should be noted
here. The carrier sleeve locking dogs 182 serve to prevent the
carrier sleeve 180 from moving before a lower shoulder 119 of the
upper stem extension 114 contacts the carrier sleeve no-go dogs
188. The locking dogs 184 serve to maintain the position of the
lockout tool 100 within the safety valve 50 during the lockout
process. The flow tube dogs 186 land on top of the flow tube 54 and
drive the flow tube 54 downward. Finally, the carrier sleeve no-go
dogs 188 shift the carrier sleeve 180 downward when contacted by
the lower shoulder 119 of the upper stem extension 114.
[0099] The precise functions of the various dogs are more fully
understood in light of the cross-sectional views of FIGS. 3A-12A,
discussed below. More specifically, FIGS. 3A-12A provide a
step-by-step presentation for actuation of the lockout tool 100. It
should again be noted that certain parts in the drawings are
sometimes darkened. This indicates that the part is either moving,
or is about to be moved.
[0100] FIG. 3A presents a cross-sectional view of a lockout tool
100 of the present invention, in one arrangement. In this view, the
lockout tool 100 has been landed in a subsurface safety valve 50.
The SSV 50 itself includes a housing 52, a bore 55 within the
housing, a non-moveable element 58 (such as a hard seat) and a
valve closure member 60, i.e. "flapper" pivotally mounted onto the
hard seat 58. The flapper 60 resides within the bore 55, and is
movable between an opened position and closed position. The safety
valve 50 also includes a flow tube 54 axially moveable within the
bore 55 of the housing 52 for controlling the movement of the
flapper 60, and an actuator, e.g., piston 57, for translating the
flow tube 54 longitudinally. Certain features of a typical SSV 50,
such as the hydraulic flow line and a spring biasing the flow tube
54 upwardly, are not shown. More details concerning features of the
safety valve itself, in one arrangement, are described in U.S.
patent application Ser. No. 09/998,800. Named inventors on that
pending application are Deaton and Jancha.
[0101] As shown in FIG. 3A, the lockout tool 100 has been lowered
into the safety valve 50 to a depth such that the lower end prong
104 has contacted the flapper 60. Further, the lower end prong 104
has forced the flapper 60 partially open. The injection of fluid at
a rate sufficient to equalize the pressure above and below the
flapper 60 within the wellbore may be provided to aid in opening
the flapper 60. In one arrangement, the lockout tool 100 may be
lowered into the wellbore using coiled tubing in lieu of a wire
line tool, with pressure being injected into the wellbore through
the coiled tubing.
[0102] In order to properly land the lockout tool 100 into the
flapper valve 50, a locating shoulder 136 is fabricated into the
outer diameter of the no-go housing 130. The locater shoulder 136
matches a beveled shoulder provided in a typical subsurface safety
valve 50. In this manner, the lockout tool 100 may be dropped to
the appropriate position within the safety valve 50 in order to
conduct the expansion operation of the present invention. More
specifically, the expander balls 105 are located at a depth that
parallels the location of the non-moveable member, e.g., hard seat
58 of the safety valve 50. In the view of FIG. 3A, the expander
balls 105 are located adjacent the hard seat 58 immediately above
the flapper 60.
[0103] In the position of the lockout tool 100 in FIG. 3A, a
downward force has not yet been applied against the stem 110. It
can be seen that the shear pin 140 has not yet been broken. Thus,
the upper 112 and lower 114 stem members and inner mandrel 170 are
held in place relative to the lockout tool housing 120. It can also
be seen that the carrier sleeve locking dog 182, the locking dog
184, the flow tube dog 186 and the carrier sleeve no-go dog 188 are
each in their run-in position, in accordance with FIG. 2.
[0104] FIG. 3B is a cross-sectional view of the lockout tool 100 of
FIG. 3A. The tool 100 is landed within the valve housing 52. The
view of FIG. 3B is taken across line B-B. More visible in this view
are three carrier sleeve locking dogs 182 disposed within the upper
housing 150. The three carrier sleeve locking dogs 182 are
supported by slots 115 machined into the stem extension 114. The
stem extension 114 is seen within the carrier sleeve locking dogs
182.
[0105] FIG. 3C presents a cross-sectional view of the lockout tool
of FIG. 3A, taken across line C-C of FIG. 3. Line C-C is just below
line B-B, and is cut across the flow tube dogs 186 and the locking
dogs 184. Visible in this view are both flow tube dogs 186 and
locking dogs 184 radially disbursed around the stem extension 114,
and carried by the carrier sleeve 180. A hydraulic chamber 56 is
seen in the valve housing 52. A piston 57 is seen within the
hydraulic chamber 56.
[0106] FIG. 3D provides a cross-sectional view of the lockout tool
of FIG. 3A, with the view taken across line D-D of FIG. 3A. Line
D-D is just below line C-C, and is cut across the no-go dogs 188.
In this view, the carrier sleeve no-go dogs 188 are seen disposed
within the upper housing 52 and the flow tube 54, and around the
expander mandrel 170. The no-go dogs 188 are carried by the carrier
sleeve 180.
[0107] Finally, FIG. 3E shows another a cross-sectional view, taken
across line E-E of FIG. 3. Line E-E is cut across the lower end 174
of the expander mandrel 170. Visible in this view are the plurality
of expander balls 105 radially disbursed around the expander
mandrel 170. In this arrangement, six balls 105 are provided,
though more or less may be employed. The balls 105 reside within
recesses 166 in the ball housing 160. A surrounding string of
production tubing 70 is seen. However, the flow tube 54 is not
seen, as it has not yet been driven downwardly.
[0108] Moving now to FIG. 4A, FIG. 4A presents a cross-sectional
view of the lockout tool 100 of FIG. 3A. In this view, the lower
stem 114 is beginning to be pushed downward into the valve housing
52. As noted, the stem 110 may be urged downward by mechanical
forces applied through spang jars. Alternatively, hydraulic
pressure provided through a working string such as coiled tubing
(not shown) may act against the stem. The shear pin 140 supporting
the upper stem 112 has been sheared. Downward movement of the upper
stem 112, in turn, exerts downward force against the lower stem
114. It can also be seen that a lower shoulder 119 in the stem
extension 114 is acting downwardly against the locking dogs 184.
Further downward movement will cause the locking dogs 184 to move
out into a recess 53 within the valve housing 52.
[0109] FIG. 4B is a cross-sectional view of the lockout tool of
FIG. 4A. The view is taken across line B-B of FIG. 4A. Visible
again in this view are the three carrier sleeve locking dogs 182
pushing outwardly against the upper housing 150. The locking dogs
182 remain disposed around the stem 114, carried by the carrier
sleeve 180.
[0110] FIG. 4C presents a cross-sectional view of the lockout tool
of FIG. 4, taken across line C-C. Visible again are the flow tube
dogs 186 and locking dogs 184 radially disbursed around the stem
extension member 114, and carried by the carrier sleeve 180. The
flow tube dogs 186 and locking dogs 184 are darkened to indicate
downward movement. The locking dogs 184 have not yet backed
outwardly, but remain adjacent the stem extension 114.
[0111] FIG. 4D provides a cross-sectional view of the lockout tool
100 of FIG. 4A, shown across line D-D of the figure. Visible again
in this D-D view are carrier sleeve no-go dogs 188 disposed within
the valve's hard seat 58, and around the expander mandrel 170. In
the view, both the stem extension member 114 and the expander
mandrel 170 are seen within the carrier sleeve no-go dogs 188. The
no-go dogs 188 are retained in this step by the upper housing 150.
The flow tube 54 is seen around the upper housing 150.
[0112] Finally, FIG. 4E shows a cross-sectional view of the lockout
tool of FIG. 4A, taken across line E-E. The plurality of expander
balls 105 are again seen around the expander mandrel 170. There is
no change in the relative position of the expander balls 105 as
compared to FIG. 3E. In this regard, the expander balls 105 remain
retracted against the smaller diameter of the expander mandrel 170
at its lower end 174.
[0113] Moving to the next step in the tool actuation process, FIG.
5A presents the lockout tool 100 of FIG. 4A, again in
cross-section. In this view, the stem 110 continues to be driven
downward into the lockout tool 100. This allows the locking dogs
182 to clear both the lower shoulder 119 in the stem extension
member 114 and the shoulder 151 in the upper housing 150 as the
stem 110 is driven further downward. The locking dogs 182 have now
been urged outwardly along the stem extension member 114, and have
engaged the profile 53 in the safety valve housing 52.
[0114] FIG. 5B presents a cross-sectional view of the lockout tool
100 of FIG. 5A. The view is taken across line B-B of FIG. 5A. The
three carrier sleeve locking dogs 182 are again seen pushing
outwardly towards the upper housing 150. There is no relative
change in the position of the carrier sleeve locking dogs 182 as
compared to FIG. 4B.
[0115] FIG. 5C provides a cross-sectional view of the lockout tool
100 of FIG. 5A, with the view taken across line C-C. Seen in this
view again are the flow tube dogs 186 and the locking dogs 184
radially disposed around the stem extension member 114, and carried
by the carrier sleeve 180. It can be seen that the locking dogs 184
have popped outwardly into the profile 53 of the valve housing
52.
[0116] FIG. 5D demonstrates a cross-sectional view of the lockout
tool 100 of FIG. 5A, taken across line D-D of FIG. 5A. The carrier
sleeve no-go dogs 188 are again shown disposed within the valve
housing 52. Both the stem extension member 114 and the upper end
172 of the expander mandrel 170 are again seen within the carrier
sleeve no-go dogs 188.
[0117] Finally, FIG. 5E shows a cross-sectional view of the lockout
tool 100 of FIG. 5A, cut through line E-E of FIG. 5A. The plurality
of radially disbursed expander balls 105 are again shown. There is
no change in the radial position of the expander balls 105 as
compared to FIGS. 3E and 4E.
[0118] The next step in the tool actuation process is presented in
FIG. 6A. FIG. 6A presents a cross-sectional view of the lockout
tool 100 of FIG. 5A. The stem extension member 114 continues to be
driven downward into the lockout tool 100. In this view, the flow
tube dogs 186 have also moved outwardly into the recess 53 in the
valve housing 52. This enables the flow tube dogs 186 to be
positioned above the piston 54.
[0119] FIG. 6B provides a cross-sectional view of the lockout tool
100 of FIG. 6A. The view is taken across line B-B of FIG. 6A. Again
visible are three carrier sleeve locking dogs 182 pushing outward
against the upper housing 150. There is no relative change in
position of the carrier sleeve locking dogs 182 as compared to FIG.
5B.
[0120] FIG. 6C demonstrates a cross-sectional view of the lockout
tool 100 of FIG. 6A, cut through line C-C. In this view, it can be
seen that both the flow tube dogs 186 and the locking dogs 184 have
expanded outwardly relative to the stem extension member 114. The
flow tube dogs 186 and locking dogs 184 extend into the recess 53
of the valve housing 52.
[0121] FIG. 6D shows a cross-sectional view of the lockout tool 100
of FIG. 6A, taken across line D-D. Visible now in the center of
this view is the lower stem 114, partially in cross-section, and
partially looking at the bottom end. This further confirms downward
movement of the stem 110 into the valve 50. The expander mandrel
170 is no longer seen, as it has been urged below line D-D.
[0122] Finally, FIG. 6E presents a cross-sectional view of the
lockout tool 100 of FIG. 6A, as shown through line E-E of FIG. 6A.
While the stem 110 and connected expander mandrel 170 have moved
downward, the enlarged outer diameter portion 176 of the expander
mandrel 170 has not yet contacted the plurality of expander balls
105. Thus, there is no change in the relative position of the
expander balls 105 as compared to FIG. 3E.
[0123] Moving now to FIG. 7A, FIG. 7A presents a cross-sectional
view of the lockout tool 100 of FIG. 6A. In this view, the lower
stem 114 continues to be driven still further into the lockout tool
100. This has enabled the carrier sleeve locking dogs 182 to clear
an upper shoulder 116 of the stem extension member 114. In
addition, the locking dogs 184 remain in the recess 53 in the valve
housing 52.
[0124] FIG. 7B provides a cross-sectional view of the lockout tool
100 of FIG. 7A. Here, the view is taken across line B-B of FIG. 7A.
Again visible in this view are the three carrier sleeve locking
dogs 182 carried by the carrier sleeve 180. It can be seen that the
carrier sleeve locking dogs 182 have been able to move inwardly due
to the reduced outer diameter 116 and the slots 115 of the stem
extension member 114.
[0125] FIG. 7C is a cross-sectional view of the lockout tool 100 of
FIG. 7A, taken across line C-C. Shown again in this view are the
flow tube dogs 186 and locking dogs 184 radially disbursed around
the stem extension member 114. An enlarged outer diameter portion
117 of the stem extension 114 is adjacent both the flow tube dogs
186 and the locking dogs 184, thereby urging these dogs 186, 184
outwardly towards the valve housing 52 and into the recess 53.
[0126] FIG. 7D provides a cross-sectional view of the lockout tool
100 of FIG. 7A, now taken across line D-D. Visible again in this
view are carrier sleeve no-go dogs 188 carried by the carrier
sleeve 180. The stem extension member 114 within the carrier sleeve
no-go dogs 188 is now a solid body, shown in cross-section. It
should also be noted from FIG. 7A that the lower shoulder 119 of
the stem extension 114 has now engaged the carrier sleeve no-go
dogs 188. As will be shown, as the stem 110 is urged further
downward, the shoulder 119 will push the carrier sleeve no-go dogs
188 and attached carrier sleeve 180 downward as well. This, in
turn, pulls the flow tube dogs 186 downward, allowing the flow tube
dogs 186 to drive the flow tube 54 downward.
[0127] Finally, FIG. 7E shows a cross-sectional view of the lockout
tool 100 of FIG. 7A, taken across line E-E of FIG. 7A. There is
again no change in the relative position of the expander balls 105,
even as compared to FIG. 3E.
[0128] The next step in the tool actuation process is shown in FIG.
8A. FIG. 8A presents the lockout tool 100 of FIG. 7A, in
cross-section. In this view, the stem 110 continues to be driven
downward into the housing 120 for the lockout tool 100. The flow
tube dogs 186 have extended further downwardly and are above the
flow tube 54 of the safety valve 50. This will allow the flow tube
dogs 186 to exert downward force against the flow tube 54. The flow
tube dogs 186 move downwardly within respective slots (seen at 153
in FIG. 1) in the upper housing 150.
[0129] FIG. 8B provides a cross-sectional view of the tool 100 of
FIG. 8A. Here, the view is taken across line B-B of FIG. 8A. Three
carrier sleeve locking dogs 182 are again visible along the carrier
sleeve 180. It is noted that the stem extension member 114 has been
driven downward to the degree that the enlarged outer diameter
portion 117 of the stem extension 114 has cleared the carrier
sleeve locking dogs 182. The diameter of the stem extension 114 is
again reduced.
[0130] FIG. 8C shows a cross-sectional view of the lock out tool
100 of FIG. 8A, cut across line C-C. The flow tube dogs 186 and
locking dogs 184 are again seen radially disposed about the carrier
sleeve 180. The flow tube dogs 186 are fully expanded outwardly
against the inner diameter of the safety valve housing 52, and are
exerting downward force against the flow tube 54.
[0131] FIG. 8D gives a cross-sectional view of the lock out tool
100 of FIG. 8A, shown through line D-D of FIG. 8A. The carrier
sleeve no-go dogs 188 are seen riding with the carrier sleeve 180.
The diameter of the stem extension 114 within the tool 100 is the
same, as the enlarged outer diameter portion 116 of the stem
extension member 114 has not yet reached the level of the carrier
sleeve no-go dogs 188.
[0132] FIG. 8E shows a cross-sectional view of the tool 100 of FIG.
8A, taken across line E-E. There still remains no visible change in
the relative position of the expander balls 105 as compared to FIG.
3E.
[0133] The next step in the tool actuation process is seen in FIG.
9A. FIG. 9A presents yet another cross-sectional view of the
lockout tool 100. In this view, the stem 110 continues to be driven
downward into the safety valve 50. The carrier sleeve 180 and
connected flow tube dogs 186 are shown driving the flow tube 54
downward towards the flapper 60. The flow tube 54 is now visible
around the ball housing 160. Also, the shoulder 119 of the stem
extension member 114 is driving the carrier sleeve no-go dogs 188
and connected carrier sleeve 180 further downward.
[0134] FIG. 9B provides a cross-sectional view of the tool of FIG.
9A, with the view being taken across line B-B. The carrier sleeve
locking dogs 182 continue to ride along the carrier sleeve 180. The
carrier sleeve locking dogs 182 have moved downward adjacent to the
locking dogs 184. Thus, the locking dogs 184 are seen disposed
adjacent the carrier sleeve locking dogs 182 around the carrier
sleeve 180.
[0135] FIG. 9C shows a cross-sectional view of the lockout tool 100
of FIG. 9A. Here, the view is shown across line C-C. The flow tube
dogs 186 are fully expanded outwardly against the inner diameter of
the safety valve housing 52, and exert downward force against the
flow tube 54 as described above. The flow tube 54 is now visible
around the ball housing 160.
[0136] FIG. 9D demonstrates a cross-sectional view of the lockout
tool 100 of FIG. 9A. The cut is taken across line D-D. Visible in
this view are carrier sleeve no-go dogs 188 disposed within the
flapper valve housing 52, and around the expander mandrel 170. The
carrier sleeve no-go dogs 188 continue to be driven downward by the
stem 110, including the stem extension member 114.
[0137] FIG. 9E is a cross-sectional view of the lockout tool 100 of
FIG. 9A, taken across line E-E. There remains no change in the
relative position of the expander balls 105 as compared to FIG. 3E.
However, the flow tube 54 is now visible around the ball housing
160.
[0138] FIG. 10A presents the next step in the actuation process for
the lockout tool 100 after the step of FIG. 9A. FIG. 10A provides a
cross-sectional view of the tool 100. In this view, the stem 110
has been driven further downward into the housing 52 for the safety
valve 50. The flow tube dogs 186 have now moved downward to the end
of their stroke. In the arrangement of FIG. 10A, the flow tube dogs
186 and connected carrier sleeve 180 stroke out when the flow tube
54 reaches the end of its stroke. At this point, of course, the
safety valve flapper 60 is completely opened. The lower shoulder
119 of the enlarged outer diameter portion 117 of the stem
extension member 114 remains in contact with the carrier sleeve
no-go dogs 188 so as to drive them downward. However, the carrier
sleeve no-go dogs 188 are now aligned with a recess 57 in the upper
housing 150. As will be seen in FIG. 11A, this will allow the
carrier sleeve no-go dogs 188 to move outwardly.
[0139] FIG. 10B provides a cross-sectional view of the lockout tool
of FIG. 10A, taken across line B-B. The carrier sleeve locking dogs
182 continue to move downward through the safety valve housing 52
with the stem 110 and the carrier sleeve 180.
[0140] FIG. 10C shows a cross-sectional view of the tool 100, with
the view being taken through line C-C of FIG. 10A. The flow tube
dogs 186 remain visible, and remain fully expanded outwardly
against the inner diameter of the safety valve housing 52. The flow
tube dogs 186 also remain shouldered out against the top of the
upper housing 150.
[0141] FIG. 10D demonstrates a cross-sectional view of the lockout
tool 100, cut through line D-D of FIG. 10A. The carrier sleeve
no-go dogs 188 continue to be driven downwardly by the shoulder 119
in the stem extension member 114.
[0142] FIG. 10E shows the lockout tool of FIG. 10A, in
cross-section. The view is taken across line E-E. There is again no
change in the position of the expander balls 105 relative to the
flow tube of the safety valve as compared to FIG. 3E. The flow tube
54 remains visible circumferentially around the ball housing 160,
keeping the flapper member 60 in its fully open position.
[0143] The next step in the tool actuation process is seen in FIG.
11A. FIG. 11A presents yet another cross-sectional view of the
lockout tool 100. In this view, the stem 110 is still driving
further downward into the safety valve 50. The carrier sleeve no-go
dogs 188 have been urged outwardly into the recess 57 in the upper
housing 150. This allows the stem extension member 114 to move
downwardly within both the carrier sleeve 180 and the flow tube 54.
This, in turn, drives the expander mandrel. 170 further downward.
As noted, the expander mandrel 170 includes an enlarged diameter
portion 176 that acts against the expander balls 105. The enlarged
diameter portion 176 can be seen now acting against the balls 105,
and driving them outwardly into the flow tube 54 of the safety
valve 50.
[0144] FIG. 11B provides a cross-sectional view of the lockout tool
100 of FIG. 11A, taken across line B-B of FIG. 11A. The position of
the carrier sleeve locking dogs 182 relative to the tool housing
120 has not changed from the view of FIG. 10B.
[0145] FIG. 11C shows the lockout tool 100 of FIG. 11A, in
cross-section. The view is taken across line C-C. There is also no
change in the position of the flow tube dogs 186 relative to the
tool housing 120.
[0146] FIG. 11D gives another cross-sectional view of the tool 100
of FIG. 11A. Here, the view is taken across line D-D. The carrier
sleeve no-go dogs 188, which have popped outwardly into the recess
57 of the upper housing 150, are adjacent the enlarged diameter
portion 117 of the stem extension member 114.
[0147] Finally, FIG. 11E provides a cross-sectional view through
line E-E. The plurality of expander balls 105 are again seen. It
can be seen that the diameter of the expander mandrel 170 has been
enlarged relative to the diameter shown in previous "E-E"
cross-section views. This causes the expander balls 105 to be
expanded outward against the flow tube 54 of the safety valve 50.
In the arrangement of FIG. 11A, the expander balls 105 have also
begun to pinch the flow tube 54 into the non-moveable hard seat 58
of the safety valve 50. This creates a profile in the hard seat 58
where it receives the flow tube 54, thereby strengthening the
frictional "lock" between the flow tube 54 and the seat 58. This,
in turn, maintains the flow tube 54 in its lowered position
adjacent the flapper 60. In this manner, the flapper 60 is locked
in its open position.
[0148] FIG. 12A presents a final cross-sectional view of the
lockout tool 100, and provides the final step in the lockout
process. In this view, the expander mandrel 170 has been driven
through the flapper 60 of the safety valve. A reduced inner
diameter portion of the mandrel 170 has reached the depth of the
expander balls 105 within the ball housing 160. This has allowed
the expander balls 105 to recess back within the ball housing 160,
and the flow tube dogs 186 to retract. This, in turn, allows the
entire tool 100 to later be removed from the wellbore with tension
placed in the slickline.
[0149] The stem extension member 114 has passed below the locking
dogs 184 such that the top end of the stem extension 114 forms a
shoulder below the locking dogs 184. This allows the operator to
pull the housing 120 and stem 110 of the tool 100 after the lockout
process is completed.
[0150] FIG. 12B is a cross-sectional view of the tool 100 of FIG.
12A, taken across line B-B. The stem 110 has been moved through the
tool housing 120 to the extent that the top end of the stem
extension member 114 is adjacent the locking dogs 184. The three
locking dogs 182 are shown in FIG. 12B disposed around the stem
extension member 114. The bottoms of the carrier sleeve locking
dogs 182 are visible in this cut.
[0151] FIG. 12C provides a cross-sectional view taken across line
C-C of FIG. 12A. It can be seen that the flow tube dogs 186 have
cleared the enlarged diameter portion 117 of the stem extension
member 114, and are recessing inward.
[0152] FIG. 12D shows the tool of FIG. 12A in cross-section, with
the view being taken across line D-D. The enlarged outer diameter
portion 176 of the expander mandrel 170 has moved below the carrier
sleeve no-go dogs 188. The carrier sleeve no-go dogs 188 are again
seen around the stem extension member's 114 diameter.
[0153] FIG. 12E shows the lockout tool 100, in cross-section, with
the view being taken across line E-E of FIG. 12A. The expander
balls 105 have retracted and are no longer expanding the radial
dimension of the flow tube 54.
[0154] It can be seen that the expansion of the flow tube 54 of the
safety valve 50 takes place radially. However, as best shown in the
cross-sectional view of FIG. 11E, the expansion is not completely
circular. In the particular arrangement shown in FIG. 11E, six
expander balls 105 are used in order to contact the surrounding
flow tube 54 and expand it outwardly against the seat 58. In order
to provide a more complete expansion, it is desirable to be able to
rotate the ball housing 160 at least 60.degree. in order to
effectuate a completely circular expansion. Accordingly, an
alternate embodiment of the present invention is provided which
allows partial rotation of the ball housing 160 during the lockout
tool actuation process.
[0155] FIG. 13 presents a section view of an alternate embodiment
of the lockout tool 100 of the present invention. In this view, a
grooved and spiraled spline 175 is placed around the expander
mandrel 170 at the level of the enlarged outer diameter portion
176. A bearing connection 165 is provided between the ball housing
160 and the lower end 154 of the upper housing 150. The allows the
ball housing 160 to rotate. Downward force urged against the
expander mandrel 170 causes the expander balls 105 to engage the
grooved and spiraled spline 175. This moves the balls outward into
engagement with the inner diameter of the flow tube 54. Further
downward jarring causes not only initial deformation of the flow
tube 54, but also rotation of the ball housing 160 and expander
balls 105. Still further rotation and expansion results in a flow
tube 54 diameter having an expanded circumferential band. This
provides an even more secure frictional engagement of the flow tube
54 against the surrounding non-moveable hard seat 58 within the
safety valve 50.
[0156] As can be seen, an improved lockout tool for locking a
subsurface safety valve in the open position has been provided.
While certain embodiments of the lockout tool have been described
and demonstrated herein, it is understood that this description is
not intended to limit the scope of the invention, but that the
actual scope of the invention is determined by the claims, which
follow. Accordingly, other and further embodiments of the lockout
tool may be provided that are within the spirit and scope of the
present invention.
[0157] It is also understood that the lockout tool has utility
outside of the context of safety valves. For example, the lockout
tool may be inserted into any tubular member for which expansion is
desired. For example, it may be desirable to expand a short section
of tubing into frictional engagement with a surrounding string of
casing in order to form a casing patch. In such an operation, the
lockout tool would provide an initial expansion of the tubing
section into frictional engagement with the surrounding casing. The
lockout tool would then be removed from the wellbore, and a rotary
expander tool would be inserted in its place. For a further
discussion of the use of a rotary expander tool for installing a
coiled tubing patch in another context, the reader is referred to
U.S. patent application Ser. No. 10/106,178 entitled "Method for
Installing an Expandable Coiled Tubing Patch." The named inventor
therein is Hoffman.
[0158] The rotary expander tool (not shown) is lowered to a depth
adjacent the tubing section (not shown). Thereafter, the expander
tool is actuated in order to further expand the tubing section into
frictional engagement with the surrounding casing. The expander
tool is further rotated and translated along a desired length
within the wellbore in order to accomplish a complete expansion. In
this manner, a tubing patch may be installed.
[0159] Other expansion applications are also contemplated within
the present invention. In this regard, the tubing patch application
represents only one such application. Again, the lockout tool may
be employed to initially expand a portion of one tubular member
into frictional engagement with another surrounding tubular member
of any type.
[0160] It should also be noted that the lockout tool 100 of the
present invention is not limited to a mechanically activated tool.
The lockout tool 100 shown in FIG. 2 and the various step-drawings
that follow is mechanically activated. In this respect, the stem
110 and connected expander mandrel 170 are urged downward through
the SSV 50 using spang jars or other mechanical-force-delivering
tool. However, the tool 100 can be quickly modified for hydraulic
actuation.
[0161] FIG. 15 shows an alternate embodiment for the lockout tool
100 of FIG. 1. In this embodiment, the lockout tool 100' is
hydraulically activated. The lockout tool 100' is seen in a side,
cross-sectional view. In order to effectuate a hydraulic
activation, various seals are placed along the lockout tool 100'.
First, a seal 131 is placed along the outer diameter of the
elongated housing 120. This serves to seal the interface between
the lockout tool 100' and a run-in tool (not shown) connected with
the working string (also not shown). In the arrangement of FIG. 15,
the seal 131 is disposed at the lower end of the no-go housing
130.
[0162] Next, seals 111 are placed along the channel 143 between the
outer diameter of the stem 110 and the inner diameter of the
housing 120. When the tool 100' is in the run-in position of FIG.
15, the seals 111 serve to prevent hydraulic fluid from passing
into the interface between the stem 110 and the housing 120. In the
arrangement of FIG. 15, one seal 111 is disposed within the top cap
142 to seal around the slidable upper stem 112, while another seal
111 is disposed around the upper stem 112 within the lock ring
spacer 147.
[0163] The lockout tool 100' of FIG. 15 also includes a pressure
relief groove 118. As will be described further below, the pressure
relief groove 118 allows fluid to temporarily vent once the lockout
tool 100' has been hydraulically actuated.
[0164] The modified lockout tool configuration of FIG. 15 is ideal
for use in deviated wells where mechanical actuation of a lockout
tool would be difficult. In operation, the upper stem 112 is
connected to the lower end of a working string (not shown). For
deviated wellbore operations, the working string is most likely a
string of coiled tubing. A run-in tool is used that provides a seal
between the inner diameter of the coiled tubing and the outer
diameter of the housing 120. The lockout tool 100' is then run into
the wellbore and landed into the housing of a safety valve (not
shown in FIG. 15).
[0165] Once the lockout tool 100' is landed into position,
hydraulic fluid is pumped into the coiled tubing. As pressure
increases within the sealed coiled tubing, the top of the upper
stem 112 begins to act as a piston surface. The stem 112 and
connected expander mandrel 170 are then urged downwardly within the
SSV 50. As described above in connection with FIGS. 3A and 4A, a
temporary mechanical connection 140 is provided between the stem
110 and the no-go housing 130. Hydraulic pressure acting on the
upper stem 112 will increase, ultimately causing the temporary
connection 140 to break. The pressure relief groove 118 along the
upper stem 112 will reach the upper cap 142, allowing hydraulic
pressure to temporarily bleed. This informs the operator that the
temporary mechanical connection 140 has been broken and the stem
110 and connected expander mandrel 170 are moving. The lockout tool
100' then progresses through the safety valve 50 as described above
in connection with FIGS. 5A-12A in order to permanently open the
flapper valve 60.
[0166] It is also noted that a combination of mechanical and
hydraulic force may be used to activate the lockout tool 100. In
this method, jars are used to break the temporary connection 140.
The coiled tubing is then pressured up in order to finish lockout.
The pressure option may also be used to release a lockout tool 100
that has become stuck in a deviated wellbore during run-in.
* * * * *